Additional PPA Agreements Reached

Maryland Community Solar Program enables renters and condo residents to subscribe to offsite solar, earn utility bill discounts, and support projects across BGE, Pepco, Delmarva, and Potomac Edison territories, with low to moderate income participation.

Key Points

A pilot allowing residents to subscribe to offsite solar and get bill credits and savings, regardless of home ownership.

✅ 5-10 percent discounts on standard utility rates

✅ Available in BGE, Pepco, Delmarva, Potomac Edison areas

✅ Includes low and moderate income subscriber carve-outs

Maryland has launched a pilot program that will allow anyone to power their home with solar panels — even if they are renters or condo-dwellers, or live in the shade of trees.

Solar developers are looking for hundreds of residents to subscribe to six power projects planned across the state, including recently announced sites in Owings Mills and Westminster. Their offers include discounts on standard electric rates.

The developers need a critical mass of customers who are willing to buy the projects’ electricity before they can move forward with plans to install solar panels on about 80 acres. Under state rules, the customer base must include low- and moderate-income residents, many of whom face energy insecurity challenges.

The idea of the community solar program is to tap into the pool of residential customers who don’t want to get their energy from fossil fuels but currently have no way to switch to a cleaner alternative.

That could significantly expand demand for solar projects, said Gary Skulnik, a longtime Maryland solar entrepreneur.

Skulnik is now CEO of Neighborhood Sun, a company recruiting customers for the six projects.

“You’re signing up for a project that won’t exist unless we get enough subscribers,” Skulnik said. “You’re actually getting a new project built.”

It could also stoke simmering conflicts over what sort of land is appropriate for solar development.

The General Assembly authorized the community solar pilot program in 2015. But not-in-my-backyard opposition and concerns about the loss of agricultural land have slowed progress.

Community solar could force more communities to confront those sorts of clashes — and to consider more carefully where solar farms belong.

“We are going to see a lot more solar development in the state,” said Megan Billingsley, assistant director of the Valleys Planning Council in Baltimore County. “One of the things we haven’t seen is any direction or thoughtful planning on where we want to see solar development.”

The General Assembly authorized about 200 megawatts in community solar projects — enough to power about 40,000 households — over three years.

Customers can sign up for projects built within the territory of their electric utility. About half of that solar energy load has been allotted for the region served by Baltimore Gas and Electric Co.

By subscribing to a community solar project, customers won’t actually be getting their electricity from its photovoltaic panels. But their payments will help finance it and, in some cases, complementary battery storage solutions as well.

The Public Service Commission has approved six projects so far: Two in BGE territory, in Owings Mills and near Westminster; one in Pepco territory, in Prince George’s County; two in Delmarva Power and Light territory, in Caroline and Worcester counties; and one in Potomac Edison territory, in Washington County where planning officials have developed proposed recommendations.

More projects are expected to win approval in the next two years.

But none of them can be built unless they catch on with electricity customers. The developers are looking for 2,600 customers statewide.

Skulnik would not say how many customers an individual project needs to get the green light. But he said that the Prince George’s proposal, a 25-acre array atop a Fort Washington landfill is the closest, with about 100 subscribers so far.

The terms of subscription vary by project, but discounts range from 5 percent to 10 percent off utility rates. Customers are asked to commit to the projects for as long as 25 years. (They can break the contracts with advance notice, or if they move to a different utility service area.)

Maryland joins more than a dozen states in advancing community solar projects, as scientists work to improve solar and wind power technology.

Corey Ramsden is an executive for Solar United Neighbors, a nonprofit that promotes the solar industry in eight states and the District of Columbia.

He said potential customers are often confused by the mechanics of subscribing to community solar, or hesitant to commit for years or even decades. The industry is working to answer questions and get people more comfortable with the idea, he said.

But it has been a challenge across the country, including debates over New England grid upgrades, and in Maryland. Advocates for solar say there is broad support for renewable energy generation. The state has set goals to increase green energy use and reduce greenhouse gas emissions.

Still, many Marylanders don’t welcome the reality when a project attempts to move in.

Rural land is often the most desirable for solar developers, because it requires the least effort to prepare for an array of panels. But community groups in those areas have asked whether land historically used for farming is right for a more industrial use.

“People are very much in favor of going for a lot more renewables, for whatever reason,” said Dru Schmidt-Perkins, the former president of the land conservation group 1,000 Friends of Maryland. “That support comes to a screeching halt when land that is perceived to be valuable for other things, whether a historic view­shed or farming, suddenly becomes a target of a location for this new project.”

Such concerns have at least temporarily stalled the momentum for solar across the state. Anne Arundel County had at least five small community solar projects in the pipeline in December when officials decided to pause development for eight months. Baltimore County officials imposed a four-month moratorium on solar development before passing an ordinance last year to limit the size and number of solar farms.

Billingsley said the Valley Plannings Council, which advocates for historic and rural areas in western Baltimore County, is frustrated that there hasn’t been more discussion about which areas the county should target for solar development — and which it shouldn’t.

She said she fears that pressure to expand solar farms across rural lands is only going to grow as community solar projects launch, and as lawmakers in Annapolis talk about more policies to promote investment in renewable energy.

Schmidt-Perkins called community solar “an amazing program” for those who would install solar panels on their roofs if they could. But she said its launch heightens the importance of discussions about a broader solar strategy.

“Most communities are caught a little flat-footed on this and are somewhat at the mercy of an industry that’s chomping at the bit,” she said. “It’s time for Maryland to say, ‘Okay, let’s come up with our plan so that we know how much solar can we really generate in this state on lands that are not conflict-based.’”

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EU Smart Meter Analytics integrates AMI data with grid edge platforms, enabling back-office efficiency, revenue assurance, and customer insights via cloud and PaaS solutions, while system integration cuts costs and improves utility performance.

Key Points

EU smart meter analytics uses AMI data and cloud to improve utility performance, revenue assurance, and outcomes.

✅ AMI underpins grid edge analytics and utility IT/OT integration

✅ Cloud and PaaS reduce costs and scale data-driven applications

✅ Focus shifts from meter rollout to back-office and revenue analytics

Europe's investment in smart meters has begun to open up the market for analytics that benefit both utilities and customers.

Two new reports from GTM Research demonstrate the substantial investment in both advanced metering infrastructure (AMI) and specific customer analytics segments -- the first report analyzes the progress of AMI deployment in Europe, while the second is a comprehensive assessment of analytics use cases, including AI in utility operations, enabled by or interacting with AMI.

The Third Energy Package mandated EU member states to perform a cost-benefit analysis to evaluate the economic viability of deploying smart meters and broader grid modernization costs across member states. Two-thirds of the member states found there was a net positive result, while seven members found negative or inconclusive results.

“The mandate spurred AMI deployment in the EU, but all member states are deploying some AMI. Even without an overall positive cost-benefit outcome, utilities found pockets of customers where there is a positive business case for AMI,” said Paulina Tarrant, research associate at GTM Research and lead author of “Racing to 2020: European Policy, Deployment and Market Share Primer.”

Annual AMI contracting peaked in 2013 -- two years after the mandate -- with 29 million contracted that year. Today, 100 million meters have been contracted overall. As member states reach their respective targets, the AMI market will cool in Europe and spending on analytics and applications will continue to ramp up, aligning with efforts to invest in smarter infrastructure across the sector, Tarrant noted.

Between 2017 and 2021, more than $30 billion will be spent on utility back-office and revenue-assurance analytics in the EU, reflecting the shift toward the digital grid architecture, according to GTM Research’s Grid Edge Customer Utility Analytics Ecosystems: Competitive Analysis, Forecasts and Case Studies.

The report examines the broad landscape of customer analytics showing how AMI interacts with the larger IT/OT environment of a utility.

“The benefits of AMI expand beyond revenue assurance -- in fact, AMI represents the backbone of many customer utility analytics and grid edge solutions,” said Timotej Gavrilovic, author of the Grid Edge Customer Utility Ecosystems report.

Integration is key, according to the report.

“Technology providers are integrating data sets, solutions and systems and partnering with others to provide a one-stop shop serving broad utility needs, increasing efficiencies and reducing costs,” Gavrilovic said. “Cloud-based deployments and platform-as-a-service offerings are becoming commonplace, creating an opportunity for utilities to balance the cost versus performance tradeoff to optimize their analytics systems and applications.”

A diverse array of customer analytics applications is a critical foundation for demonstrating the positive cost-benefit of AMI.

“Advanced analytics and applications are key to ensuring that AMI investments provide a positive return after smart meters are initiated,” said Tarrant. “Improved billing and revenue assurance was not enough everywhere to show customer benefit -- these analytics packages will leverage the distributed network infrastructure, including advanced inverters used with distributed energy resources, and subsequent increased data access, uniting the electricity markets of the EU.”

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Canada Electricity Grid Decarbonization advances net-zero goals by expanding renewable energy (wind, solar, hydro), boosting grid reliability with battery storage, and aligning policy, efficiency, and investment to cut emissions and strengthen energy security.

Key Points

Canada's shift to low-carbon power using renewables and storage to cut emissions and improve grid reliability.

✅ Invest in wind, solar, hydro, and transmission upgrades

✅ Deploy battery storage to balance intermittent generation

✅ Support just transition, jobs, and energy efficiency

As Canada moves towards a more sustainable future, decarbonizing its electricity grid has emerged as a pivotal goal. The transition aims to reduce greenhouse gas emissions, promote renewable energy sources, and ultimately support global climate targets, with cleaning up Canada's electricity widely viewed as critical to meeting those pledges. However, the implications of this transition are multifaceted, impacting the economy, energy reliability, and the lives of Canadians.

Understanding Decarbonization

Decarbonization refers to the process of reducing carbon emissions produced from various sources, primarily fossil fuels. In Canada, the electricity grid is heavily reliant on natural gas, coal, and oil, which contribute significantly to carbon emissions. The Canadian government has committed to achieving net-zero by 2050 through federal and provincial collaboration, with the electricity sector playing a crucial role in this initiative. The strategy includes increasing the use of renewable energy sources such as wind, solar, and hydroelectric power.

Economic Considerations

Transitioning to a decarbonized electricity grid presents both challenges and opportunities for Canada’s economy. On one hand, the initial costs of investing in renewable energy infrastructure can be substantial. This includes not only the construction of renewable energy plants but also the necessary upgrades to the grid to accommodate new technologies. According to the Fraser Institute analysis, these investments could lead to increased electricity prices, impacting consumers and businesses alike.

However, the shift to a decarbonized grid can also stimulate economic growth. The renewable energy sector is a rapidly growing industry that, as Canada’s race to net-zero accelerates, promises job creation in manufacturing, installation, and maintenance of renewable technologies. Moreover, as technological advancements reduce the cost of renewable energy, the long-term savings on fuel costs can benefit both consumers and businesses. The challenge lies in balancing these economic factors to ensure a smooth transition.

Reliability and Energy Security

A significant concern regarding the decarbonization of the electricity grid is maintaining reliability and energy security, especially as an IEA report indicates Canada will need substantially more electricity to achieve net-zero goals, requiring careful system planning.

To address this challenge, the implementation of energy storage solutions and grid enhancements will be essential. Advances in battery technology and energy storage systems can help manage supply and demand effectively, ensuring that energy remains available even during periods of low renewable output. Additionally, integrating a diverse mix of energy sources, including hydroelectric power, can enhance the reliability of the grid.

Social Impacts

The decarbonization process also carries significant social implications. Communities that currently depend on fossil fuel industries may face economic challenges as the transition progresses, and the Canadian Gas Association has warned of potential economy-wide costs for switching to electricity, underscoring the need for a just transition.

Furthermore, there is a need for public engagement and education on the benefits and challenges of decarbonization. Canadians must understand how changes in energy policy will affect their daily lives, from electricity prices to job opportunities. Fostering a sense of community involvement can help build support for renewable energy initiatives and ensure that diverse voices are heard in the planning process.

Policy Recommendations

For Canada to successfully decarbonize its electricity grid, and building on recent electricity progress across provinces nationwide, robust and forward-thinking policies must be implemented. This includes investment in research and development to advance renewable technologies and improve energy storage solutions. Additionally, policies should encourage public-private partnerships to share the financial burden of infrastructure investments.

Governments at all levels should also promote energy efficiency measures to reduce overall demand, making the transition more manageable. Incentives for consumers to adopt renewable energy solutions, such as solar panels, can further accelerate the shift towards a decarbonized grid.

Decarbonizing Canada's electricity grid presents a complex yet necessary challenge. While there are economic, reliability, and social considerations to navigate, the potential benefits of a cleaner, more sustainable energy future are substantial. By implementing thoughtful policies and fostering community engagement, Canada can lead the way in creating an electricity grid that not only meets the needs of its citizens but also contributes to global efforts in combating climate change.

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UK Free Electricity Debate weighs soaring energy prices against market regulation, renewables, and social equity, examining price caps, funding via windfall taxes, grid investment, and consumer protection in the UK's evolving energy policy landscape.

Key Points

A policy dispute over free power, balancing consumer relief with market stability, renewables, and investment.

✅ Pros: relief for households; boosts efficiency and green adoption.

✅ Cons: risks to market signals, quality, and grid investment.

✅ Policy options: price caps, windfall taxes, targeted subsidies.

In recent months, the debate over free electricity in the UK has intensified, revealing a divide within the energy sector. With soaring energy prices and economic pressures impacting consumers, the discussion around providing free electricity has gained traction. However, the idea has sparked significant controversy among industry stakeholders, each with their own perspectives on the feasibility and implications of such a move.

The Context of Rising Energy Costs

The push for free electricity is rooted in the UK’s ongoing energy crisis, exacerbated by geopolitical tensions, supply chain disruptions, and the lingering effects of the COVID-19 pandemic. As energy prices reached unprecedented levels, households faced the harsh reality of skyrocketing bills, prompting calls for government intervention to alleviate financial burdens.

Supporters of free electricity argue that it could serve as a vital lifeline for struggling families and businesses. The proposal suggests that by providing a certain amount of electricity for free, the government could help mitigate the effects of rising costs while encouraging energy conservation and efficiency.

Industry Perspectives

However, the notion of free electricity has not been universally embraced within the energy sector. Some industry leaders express concerns about the financial viability of such a scheme. They argue that providing free electricity could undermine the market dynamics that incentivize investment in infrastructure and renewable energy, in a market already exposed to natural gas price volatility today. Critics warn that if energy companies are forced to absorb costs, it could lead to diminished service quality and investment in necessary advancements.

Additionally, there are worries about how free electricity could be funded. Proponents suggest that a tax on energy companies could generate the necessary revenue, but opponents question whether this would stifle innovation and competition. The fear is that placing additional financial burdens on energy providers could ultimately lead to higher prices in the long run.

Renewable Energy and Sustainability

Another aspect of the debate centers around the UK’s commitment to transitioning to renewable energy sources. Supporters of free electricity emphasize that such a policy could encourage more widespread adoption of green technologies by making energy more accessible. They argue that by removing the financial barriers associated with energy costs, households would be more inclined to invest in solar panels, heat pumps, and other sustainable solutions.

On the other hand, skeptics contend that the focus should remain on ensuring a stable and reliable energy supply as the UK moves toward its climate goals. They caution against implementing policies that might disrupt the balance of the energy market, potentially hindering the necessary investments in renewable infrastructure.

Government's Role

As discussions unfold, the government’s role in this debate is crucial. Policymakers must navigate the complex landscape of energy regulation, market dynamics, and consumer needs. The government has already introduced measures aimed at assisting vulnerable households, such as energy price caps and direct financial support. However, the question remains whether these initiatives go far enough in addressing the root causes of the energy crisis.

In this context, the government faces pressure from both consumers demanding relief and industry leaders advocating for market stability, including proposals to end the link between gas and electricity prices to curb price volatility. The challenge lies in finding a middle ground that balances immediate support for households with long-term sustainability and investment in the energy sector.

Future Implications

The ongoing debate about free electricity in the UK underscores broader themes related to energy policy, market regulation, and social equity, with rising electricity prices abroad offering context for comparison. As the country navigates its energy transition, the decisions made today will have far-reaching implications for both consumers and the industry.

If the government chooses to pursue a model that includes free electricity, it will need to carefully consider how to implement such a system without jeopardizing the market. Transparency, stakeholder engagement, and thorough impact assessments will be essential to ensure that any new policies are sustainable and equitable.

Conversely, if the concept of free electricity is ultimately rejected, the focus will likely shift back to addressing energy costs through other means, such as enhancing energy efficiency programs or increasing support for vulnerable populations.

The divide within the UK’s energy industry regarding free electricity highlights the complexities of balancing consumer needs with market stability. As the energy crisis continues to unfold, the conversations surrounding this issue will remain at the forefront of public discourse. Ultimately, finding a solution that addresses the immediate challenges while promoting a sustainable energy future will be key to navigating this critical juncture in the UK’s energy landscape.

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FERC Rejects Trump Coal Plan, denying subsidies for coal-fired and nuclear plants as energy policy shifts toward natural gas and renewables, citing no grid reliability threat and warning about electricity prices and market impacts.

Key Points

FERC unanimously rejected subsidies for coal and nuclear plants, finding no grid reliability risk from retirements.

✅ Unanimous FERC vote rejects coal and nuclear compensation

✅ Cites no threat to grid reliability from plant retirements

✅ Opponents warned subsidies would distort power markets and prices

A decision by an independent energy agency to reject the Trump administration’s electricity pricing plan to bolster the coal industry could lead to more closures of coal-fired power plants and the loss of thousands of jobs, a top coal executive said Tuesday.

Robert Murray, CEO of Ohio-based Murray Energy Corp., called the action by the Federal Energy Regulatory Commission “a bureaucratic cop-out” that will raise the cost of electricity and jeopardize the reliability and security of the nation’s electric grid.

“While FERC commissioners sit on their hands and refuse to take the action directed by Energy Secretary Rick Perry and President Donald Trump, the decommissioning of more coal-fired and nuclear plants could result, further jeopardizing the reliability, resiliency and security of America’s electric power grids,” Murray said. “It will also raise the cost of electricity for all Americans.”

The five-member energy commission voted unanimously Monday to reject Trump’s plan to reward nuclear and coal-fired power plants for adding reliability to the nation’s power grid. The plan would have made the plants eligible for billions of dollars in government subsidies and help reverse a tide of bankruptcies and loss of market share suffered by the once-dominant coal industry as utilities' shift to natural gas and renewable energy continues.

The Republican-controlled commission said there’s no evidence that any past or planned retirements of coal-fired power plants pose a threat to reliability of the nation’s electric grid.

Murray disputed that and said the recent cold snap that hit the East Coast showed coal’s value, as power users in the Southeast were asked to cut back on electricity usage because of a shortage of natural gas. “If it were not for the electricity generated by our nation’s coal-fired and nuclear power plants, we would be experiencing massive brownouts risk and blackouts in this country,” he said.

Murray Energy is the largest privately owned coal company in the United States, with mining operations in Ohio, Illinois, Kentucky, Utah and West Virginia. Robert Murray, a Trump friend and political supporter, has been pushing hard for federal assistance for his industry. The Associated Press reported last year that Murray asked the Trump administration to issue an emergency order protecting coal-fired power plants from closing. Murray warned that failure to act could cause thousands of coal miners to be laid off and force his largest customer, Ohio-based FirstEnergy Solutions, into bankruptcy.

Perry ultimately rejected Murray’s request, but later asked energy regulators to boost coal and nuclear plants as the administration moved to replace the Clean Power Plan with a more limited approach.

The plan drew widespread opposition from business and environmental groups that frequently disagree with each other, even as some coal and business interests backed the EPA's Affordable Clean Energy rule in court.

Jack Gerard, president and CEO of the American Petroleum Institute, said Tuesday that the Trump plan was “far too narrow” in its focus on power sources that maintain a 90-day fuel supply.

API, the largest lobbying group for oil and gas industry, supports coal and other energy sources, Gerard said, “but we should not put our eggs in an individual basket defined as a 90-day fuel supply (while) unnecessarily intervening in private markets.”

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Ontario-Quebec Electricity Deal explores hydro imports, terawatt hours, electricity costs, greenhouse gas cuts, and baseload impacts, amid debates on Pickering nuclear operations and competitive procurement in Ontario's long-term energy planning.

Key Points

A proposed hydro import deal from Quebec, balancing costs, emissions, and reliability for Ontario electricity customers.

✅ Draft 20-year, 8 TWh offer reported by La Presse disputed

✅ Ontario seeks lower costs and GHG cuts versus alternatives

✅ Not a baseload replacement; Pickering closure not planned

Ontario is negotiating a possible energy swap agreement to buy electricity from Quebec, but the government is disputing a published report that it is preparing to sign a deal for enough electricity to power a city the size of Ottawa.

La Presse reported Tuesday that it obtained a copy of a draft, 20-year deal that says Ontario would buy eight terawatt hours a year from Quebec – about 6 per cent of Ontario’s consumption – whether the electricity is consumed or not.

Ontario Energy Minister Glenn Thibeault’s office said the province is in discussions to build on an agreement signed last year for Ontario to import up to two terawatt hours of electricity a year from Quebec.

But his office released a letter dated late last month to his Quebec counterpart, in which Mr. Thibeault said the offer extended in June was unacceptable because it would increase the average residential electricity bill by $30 a year.

“I am hopeful that your continued support and efforts will help to further discussions between our jurisdictions that could lead to an agreement that is in the best interest of both Ontario and Quebec,” Mr. Thibeault wrote July 27 to Pierre Arcand.

Ontario would prepare a “term sheet” for the next stage of discussions ahead of the two ministers meeting at the Energy and Mines Ministers Conference later this month in New Brunswick, Mr. Thibeault wrote.

Any future agreements with Quebec will have to provide a reduction in Ontario electricity rates compared with other alternatives and demonstrate measurable reductions in greenhouse gas emissions, he wrote.

Progressive Conservative Leader Patrick Brown said Ontario doesn’t need eight terawatt hours of additional power and suggested it means the Liberal government is considering closing power facilities such as the Pickering nuclear plant early.

A senior Energy Ministry official said that is not on the table. The government has said it intends to keep operating two units at Pickering until 2022, and the other four units until 2024.

Even if the Quebec offer had been accepted, the energy official said, that power wouldn’t have replaced any of Ontario’s baseload power because it couldn’t have been counted on 24 hours a day, 365 days a year.

The Society of Energy Professionals said Mr. Thibeault was right to reject the deal, but called on him to release the Long-Term Energy Plan – which was supposed to be out this spring – before continuing negotiations.

Some commentators have argued for broader reforms to address Ontario's hydro system challenges, urging policymakers to review all options as negotiations proceed.

The Ontario Energy Association said the reported deal would run counter to the government’s stated energy objectives amid concerns over electricity prices in the province.

“Ontarians will not get the benefit of competition to ensure it is the best of all possible options for the province, and companies who have invested in Ontario and have employees here will not get the opportunity to provide alternatives,” president and chief executive Vince Brescia said in a statement. “Competitive processes should be used for any new significant system capacity in Ontario.”

The Association of Power Producers of Ontario said it is concerned the government is even considering deals that would “threaten to undercut a competitive marketplace and long-term planning.”

“Ontario already has a surplus of energy, so it’s very difficult to see how this deal or any other sole-source deal with Quebec could benefit the province and its ratepayers,” association president and CEO David Butters said in a statement.

The Ontario Waterpower Association also said such a deal with Quebec would “present a significant challenge to continued investment in waterpower in Ontario.”

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